field development project
TRANSCRIPT
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FIELD DEVELOPMENT PROJECT PRESENTATION
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Presentation Outline Corporate Profile Lithology Log Interpretations Findings Appraisal Well Location
Drilling Design Conclusion
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Corporate Profile
PHOENIXENERGY is the oil and gas operator company of which based inMalaysia and were found on 1985. Together with its subsidiaries andassociated companies, PHOENIXENERGY, a FORTUNE Global 500company, has fully integrated oil and gas operations in a broad spectrum ofthe oil and gas value-chain.
Its business activities include ; (i) the exploration, development and production of crude oil and naturalgas in Malaysia and overseas;(iv) the refining and marketing of petroleum products;
(v) the manufacture and sale of petrochemical products;(vi) the trading of crude oil, petroleum products and petrochemicalproducts;(vii) shipping and logistics relating to LNG, crude oil and petroleumproducts.
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VisionPHOENIXENERGYwants to be recognised as a greatcompany competitively successful and a force forprogress. We have a fundamental belief that we can make a
difference in the world. Mission To generate consistently profitable returns from
investments in core business activities. Providing direction, financial resources and management
support for each operating unit. Through dynamic and innovative management,
teamwork and a commitment to excellence.
Vision&Mission
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Organizational Chart
Asha KanamuthyReservoir Engineer
Norazri NordinSenior Quality, Health, Safety and Environment (QHSE) Manager
Muhammad Faidhi Fahmi IsmailCHIEF EXECUTIVE OFFICER/Economist
Nur Amirah BasiranSenior Production Manager
Tajuddin Tapri
Senior Reservoir ManagerSaiful SaariAssociate Petrophysicist
Hesham IsmailSenior Drilling Manager
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FieldSummary
Geological Area : Sabah BasinArea : Offshore Sabah
Country : MalaysiaLocation : 113 kilometers Southwest of
Kimanis Oil & Gas Terminal
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GEOLOGY AND PETROPHYSICSAMIRAH BASIRAN, GEOLOGIST
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Data Provided Phoenix Fields Profile Exploration Well Static Pressure Gradient Well Correlation
Productive Layer Distribution Conclusion
Presentation Outline
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Data ProvidedData Source Well 1 Well 2 Well 3 Well 4
PVT Data /Static P
Gradient / / / /
Gamma Ray / / / /
SP / / / /
Resitivity / / / /
Density / / / /
Sonic / / / /
Neutron / / / /
Mud Log / / / /
Core Data /
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Sabah BasinGeological Area
Sandstone Group E from earlyMiocene ageFormation
Fluviodeltaic source rockSource Rock
Cross strata migrationMigration
AnticlinesReservoir Structure Longitude 115 32 24E, Latitude 6 42 00N 113 kilometres southwest of the Kimanis Oil & Gas
TerminalLocation
4Exploration Well
Phoenix Fields Profile
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Phoenix Field
113 km
Geological Area : Sabah Basin
Area : Offshore Sabah
Location : 113km from the
Kimanis Oil & Gas Terminal
Block : 7T-11
Nearest Field : Gajah Hitam,
Rusa Timur, Mengkira, Dengkis
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Phoenix Field
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Contour Map
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Exploration WellWELL CLASSIFICATION DISCOVERY DEPTH OF
RECORDED (ft)
Well 1 Exploration well Oil 5975 - 6290Well 2 Exploration well Oil 6125 - 6429Well 3 Exploration well Oil 6425 - 6737
Well 4 Exploration well Water 6561 - 6877
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Static Pressure Gradient Graph of Phoenix Field
ll l b d
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Well Correlation based on GammaRay Log
W ll 1
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Well 1
Well 2
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Well 2
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Productive Layer
Layer BulkVolume
(MM ft3)
Porosity Boi Swi Soi STOIIP(MMST
B)AB1 1900 0.21 1.39 0.14 0.86 197
AB2 789 0.24 1.35 0.14 0.86 92Total 289
Reservoir Oil Sand
Thickness (ft)
OWC (ft) Net to gross
ratio (N/G)
FD1 Oil 55 6480 0.8
FD2 Oil 55 6480 1.0
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Porosity Distribution
Zone 1 Zone 2
0
5
10
15
20
25
0.09 0.15 0.21 0.27 0.29 0.35 0.42
F r e q u e n c y
Porosity
0
5
10
15
20
25
30
9 15 21 24 33 42
F r e q u e n c y
Porosity
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Water Saturation Distribution
Zone 1 Zone 2
0
5
10
15
20
25
9 10 12 14 16 19 21 22 23 26 30 31 33
F r e q u e n c y
Water Saturation (%)
0
2
4
6
8
10
12
14
16
18
20
8 10 12 14 22 24 26 28
F r e q u e n c y
Water Saturation (%)
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Oil Saturation DistributionZone 1 Zone 2
0
5
10
15
20
25
30
67 69 70 73 81 84 85 86 88 90 92 94 96 98 100
F r e q u e n c y
Oil Saturation (%)
0
5
10
15
20
25
30
35
72 76 78 80 86 88 90 92
F r e q u e n c y
Oil Saturation (%)
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Percentile STOIIP(MMSTB)
P90 130
P50 197
P10 305
Percentile STOIIP(MMSTB)
P90 60
P50 92
P10 125
STOIIP at P50 = 92 MMSTB
STOIIP at P50 = 197 MMSTB
Zone FD1
Zone FD2
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Conclusion
Phoenix Field have 2 productive layers containoil
Total Initial Oil In-Place at P50 = 289 MM resBbl.
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Appendixes
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Source Rock
Late Oligocene: Limestone
Early Miocene :Sandstone, Siltstone,conglomerate with
metamorphic, chert,volcanics (shallow
water)
Thickness of beds: varies from a few
centimeters toone meter
Slumps &
Channelinfillings
Stronglyisoclinal folded
Sandstones
with thickturbidites
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Permeability Distributions Zone 1 Zone 2
0
5
10
15
20
25
30
35
40
45
310
F r e q u e n c y
Permeability (mD)
k Distribution
k Distribution
0
5
10
15
20
25
30
35
40
45
343
F r e q u e n c y
Permeability (mD)
k Distribution
k Distribution
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Zone FD1
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Zone FD2
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Contour Map
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RESERVOIRASHA KANAMUTHY, RESERVOIR ENGINEER
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Rock Properties Oil Properties Gas Properties Water Properties Well Test
Phase Envelope Risk Analysis
Presentation Outline
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ROCK PROPERTIESZone Zone FD1 Zone FD2
Type Of Hydrocarbon Oil Oil
Lithology Sandstone
Average Permeability, K (mD) 313 343
Average Porosity, (fraction) 0.21 0.24
Initial Water Saturation, S wi (fraction) 0.14 0.14
Reservoir
(Zone)
Datum
(ft subsea)
Pressure
(psia)
Temperature
(0F)
FD16055 2806 210
FD2 6135 2884 215
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OIL PROPERTIES
Zone Zone FD1 Zone FD2
Pi (psia) 2806 2884
T(F) 210 215
P b(psia) 2342 2634
API 31.7 35.4
R s(SCF/STB) 977.6 854.0
Bo(bbl/STB) 1.39 1.35
co(psia -1) 2.075e-05 2.112e-05
o(cp) 0.2383 0.373
o 0.867 0.848
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GAS & WATER PROPERTIES
Zone Zone FD1 Zone FD2
Z 0.827 0.796
g (cp) 0.0234 0.0219 g 0.893 0.89
cg (psi -1) 3.014e-04 2.92e-04
Zone Zone FD1 Zone FD2
Bw (bbl/STB) 1.032 1.034
w(cp) 0.2831 0.2730
cw (psi -1) 3.1696e-06 3.2002e-06
GAS PROPERTIES
WATER PROPERTIES
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Solution gas oil ratio vs Pressure
Bg vs PressureBo vs Pressure
Oil viscosity vs Pressure
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WELL TEST
Zone FD1 k=311mD S=6
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WELL TEST
Zone FD2 k=343mD S=5
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PHASE ENVELOPE
Zone FD1
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Zone FD2
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RISK ANALYSIS ZONE FD1
P10 290 MM STB
P50 197 MM STB
P90 130 MM STB
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RISK ANALYSIS ZONE FD2
P10 130 MM STB
P50 92 MM STB
P90 55 MM STB
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RESERVOIR SIMULATIONTAJUDDIN TAPRI, SIMULATION ENGINEER
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MODEL CONSTRUCTION
Enlarge and grid the contour map
Create static model
Create dynamic model
Run simulation based on study parameters
Observe result
Production, drilling, well completion and economics evaluation
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STATIC MODEL
Zone L 1
Zone L 2
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Zone L 1 ( IOIP = 197.2 MM bbl )
Zone L 1 ( IOIP = 92.5 MM bbl )
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SENSITIVITY RUN
3 cases
A 2000 ft
B 1500 ft
C 1000 ft
DYNAMICMODEL
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Plan B Result
Zone L 1
Zone L 2
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Plan C Result
Zone L 1
Zone L 2
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SummaryPlan Reserv
oirQ(bbl/
d)Plateau
rate(bbl/d)
TotalPlateau
rate(bbl/d)
PlateauPeriod(Year)
EUR(MMST
B)
TotalEUR
(MMSTB)
RF(%)
TotalRF(%)
A
2000ft
Zone
FD1
2200 17600 32000 8 56.3 81.5 28.5 28.2
ZoneFD2
1800 14400 4 25.2 27.4
B1500ft
ZoneFD1
2200 26400 48000 4 59.1 87.6 30 30.3
ZoneFD2 1800 21600 3 28.5 30.1
C1000ft
ZoneFD1
2200 35200 64000 3 59.2 84 30.1 29.1
Zone
FD2
1800 28800 2 24.8 27
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Supplemental Recovery
PLAN B
WATER INJECTION
GAS INJECTION
SENSITIVITYANALYSIS
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RESULT AND ANALYSIS
SecondaryRecovery
Reservoir Number
Ofinjection
well
Injectionrate
Injectiondate
PlateauRate
(bbl/d)
PlateauPeriod(year)
RF(%)
TotalRF(%)
EUR(MM bbl)
GasInjection Zone L1
2 WPRD
convert toGINJ
5
MMScf/d
1-June-
2017
15600
9 35.5
35.5 102.56
Zone L22 WPRDconvert to
GINJ
5MMScf/d
1-Feb-2016
9600
6 36.0
WaterInjection
Zone L1 2 WPRDconvert to
GINJ
10000bbl/d
1-June -
2017
1560010 37.5
37.6108.84
Zone L2 2 WPRDconvert to
GINJ
10000bbl/d
1-Feb -2016
96007 38.0
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Zone L 1
Zone L 2
WATERINJECT.
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CONCLUSIONS
PLAN B BEST RESULT Economic evaluation will be run for these
three plans
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WELL DRILLINGHESHAM ISMAIL, DRILLING ENGINEER
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Objective Casing seating depth. Mud program. Casing design. Cementing program Drill Bit selection. Blowout Preventer design(BOP)
Presentation Outline
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Casing setting Depth Fracture gradient Mud gradient Formation pressure gradient
KEY Parameters
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DRILLING FLUID The drilling fluids that being use is Oil Based
Mud
Additives : such as Barite, KCL, Flo-Tro, NaOHand Xantham gum polymer.
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CASING DESIGN
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Cementing API G Class . e.g : well #1
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Drill Bit Selection
-Drill Pipe = X-95, 13.8 lb/ft-Drill Collar = 50 lb/ft , 5 OD
For bit selection, the result are shown below
Casing type Casing OD Bit Size
Conductor 20 26 Rolling CutterBit
Surface 13 3/8 17 RollingCutter BitIntermediate 9 5/8 12 PDC Bit
Production 7 8 PDC Bit
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WELL COMPLETIONNORAZRI NORDIN, COMPLETION ENGINEER
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Type of Completion Tubing Selection
Packer Selection Perforation Technique Completion Fluid Wellhead design Conclusion
Presentation Outline
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Type of Completion
Dual String Tubing Completion
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Completion Technique
Cased hole completion with shape chargeperforation:
Sand problem issue can be preventedespecially during high flow rate
Formation can be selectively stimulated
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Tubing Specifications
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Packer Selection
XHP Premium Production Packer Advantage :
i)Suitable for high pressure and hightemperature environments
ii) Prevent debris build up above slips
iii) Minimize casing damage
iv) Tensile & compressive rating compatible withcompletion tubular
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Perforation Technique
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Penetrating charges are able to createdeep perforation tunnels with smallopening diameters
Reduce rig time by eliminating wirelineruns
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Conclusion
Well Completion Department will achieve thedepartment objectives and followed the companys
plan as well hopefully all the suggestions and recommendations
from department will be able to meet theeconomical target in order to develop this field
safely, efficiently, effectively and reliably
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WELL PRODUCTIONSAIFUL SAARI, PRODUCTION TECHNOLOGIST
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Field Location Introduction
Present and Future IPR
IPR, VLP and CP Curves
Production Analysis
Platform
Surface facilities
Presentation Outline
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INTRODUCTION
Evaluate deliverability of Phoenix Field Analyze fluid flow from:
Reservoir to wel lbore
(Inflow performance relationship) Bot tom -hole to su r face
(Vertical lift performance) Wellhead to s eparator
(Choke performance)
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Zone 1
0
500
1000
1500
2000
2500
3000
0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000
P w
f
q
Present and Future IPR
2013
20152017
2019
2021
2023
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Zone 2
0
500
1000
1500
2000
2500
3000
3500
0 5000 10000 15000 20000 25000 30000 35000 40000 45000 50000
P w
f
q
Present and Future IPR
20132015
2017
2019
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Zone 1
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000
P w
f
Q
IPR, VLP & CP Curve
Qopt =1300BPD
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Zone 2
0
500
1000
1500
2000
2500
3000
3500
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000
P w
f
Q
IPR, VLP & CP Curve
Qopt =600BPD
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PRODUCTION ANALYSIS
PI 25.9971
Pwf 2853.23
Qmax 51927.34
PI 47.5651
Pwf 2793.39
Qmax 86322.61
Q1300Bbl/Day
TUBING 3.5 inch
CHOKE 24/64 inch
THP 440 psi
Q800Bbl/Day
TUBING 2.875 inch
CHOKE24/64inch
THP 330 psi
ZONE 1 ZONE 2
PLATFORM
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PLATFORM
Jack up platform will be used. Completed with drilling
module
Wellhead will be installed onthe subsea
Lower cost (economical) Long term flexibility
Intelsat communicationsystem
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SURFACE FACILITIES SEPARATOR
1. Type of separator that will be installed isvertical separator.
2. Two stages of separator:
a) First stage - To separate the liquid andgasb) Second stage To separate oil and
waterc) Third stage - Storage tank
3. The vertical separator has been chosen: Easy to install and cheap. More efficient. Easy to clean. Reduce the space area for installation.
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FLOATING PRODUCTION STORAGE AND OFFLOADING(FPSO)
FPSO will used as storage tanks tokeep the oil until the shuttle tankerscome and take over for
transportationLocated 2 km away from the platform
The produced oil will be loaded toFPSO
Facilities as production module,helideck, accommodation, controlroom and utilities
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The separation, the gas treatment and the water treatment
and injection module
Produced gas will be directed to flare
CONCLUSION
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CONCLUSION
Platform used : mobile jack up platform
Separator used : 3-phase and 2-phase verticalseparator
FPSO
ZONE 1 ZONE 2
Q = 1300 BPD Q = 800 BPD
Tubing size = 3.5 inch OD Tubing size = 2.875 inch OD
Choke size = 24/64 inch Choke size = 24/64 inch
THP = 440 psi THP = 330 psi
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ECONOMIC EVALUATIONFAIDHI FAHMI, ECONOMIST
P t ti O tli
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Presentation Outline
Company Policies Real-time Scenario Economic Models 1997 R/C PSC OPEX/CAPEX Sensitivity Analysis Analysis
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Company Policies
1. The top priority of the economic department: The top priority of the economic division is to
maximize the profit. Expand the production capacity of the invested
project. Increase in market share and value of assets
posses by the company.
2. Minimum rate of return (MROR): MROR for Global Top Corp is set at 18%
R l Ti S i
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Real Time Scenario
Determination of Oil Price Oil price is to be set at USD 90 with 5% price
escalation due to inflation and other factors
2. LOCAL SCENARIO PSC 1997 - Production Period (20 years)
- Royalty (10%)- Export Duty (10%)
- Cost Oil- Profit Oil
E i M d l
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Economic Model
Contract Period
- Contract Duration 19 YEARS
- Exploration Period 3 YEARS- Development Period 2 YEARS
- Production Period 15 YEARS
1997 R/C PSC
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1997 R/C PSC
GROSS REVENUE
LESS COST : COST OIL CEILING
PROFIT OIL SPLIT
UNUSED COSTOIL
PETRONASPROFIT OIL
ACTUAL USED
COST
CONTRACTOR
PROFIT OIL
PITA 38%
PITA 38%
ROYALTY 10% G O V E R N
ME N
T C A S H F L O W
CAPEX
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CAPEX The management decide to acquire FPSO by
purchasing used vessel and transforming it into FPSOwhich undergo RLEC process
Affected the CAPEX significantly but the NPV will increasedue to the reduce in OPEX and maintenance cost
Vessel Purchase USD 18 mil
Topside USD 152 mil
Hull & Marine USD 11 mil
Riser & Mooring USD 28 mil
Hook up & Commissioning USD 43 mil
Engineering Design USD 6 mil
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OPEX OPEX mainly focused on Operation &
Maintenance, Charter Rate for FSO andOverhead Cost which already been set up toat most 15% from the gross revenue perannum
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NPV @ 18%($USD billion)
IRR(%)
PIR(Ratio)
Charter FPSO & FSO +Jack up Platform
1.3 24 7.5Charter FPSO & FSO +
Unman Platform 1.2 24 8.0Purchase FPSO ,
Charter FSO +Jack Up
1.0 22 7.0
Purchase FPSO,Charter FSO+Unman Platform
1.5 25 9.1
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NPV @ 18%($USD billion)
IRR(%)
PIR(Ratio)
Water Injection 1.3 24 7.5Gas Injection 1.2 24 8.0
Cash Flow
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Cash Flow
Payback period
Ultimate Cash Surplus
Economic Life
Maximum Cash Sink
Economic Limit years
EXPLORATION &DEVELOPMENT
PRODUCTION A B
A ND
O N M
E N T
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N E T P R E S E N T V A L U E
DISCOUNTED RATE
NPV @ 10% = USD 357 mil
NPV @ 15% = USD 241 mil
NPV @ 20% = USD 172 mil
NPV @ 29% = USD 0 mil
10% 15% 20% 10%
IRR = 34%
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Sensitivity Analysis for NPV
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Sensitivity Analysis for NPV
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QUALITY, HEALTH, SAFETY & ENVIRONMENTNORAZRI NORDIN, QHSE ENGINEER
Presentation Outline
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Health, Safety and Environmental Principles Safety Management System Basic Safety Rule Personal Protection Cleanliness And Good Housekeeping Fire And Safety Design Emergency Plan
Presentation Outline
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Health, Safety and Environmental Principles
To treat health, safety and environmentalconsiderations as priority in the projectplanning and works,
To operate our facilities and provide ourservices in a manner that always maintain thestandard of our employees, public health andsafety and the environmental practices
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Health, Safety and Environmental Principles To constantly formulate and improve the company
Health, Safety and Environmental practices based onemployees, clients and public concerns to helpsafeguard of the workplaces, community andenvironment
To actively participate with governments and otherresponsible bodies in meeting the industrial rules andregulations of health, safety and environment
To develop and implement procedures for the properstorage, transportation and disposal of waste materialsand to minimize pollutant emissions
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Safety Management System
Position that responsible for management ofsafety: General Manager Operations line-manager Line managers Operations staffs
Basic Safety Rule
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Basic Safety Rule
Understand the job Assess any possible hazard before start the
work Attend safety meeting Must familiarize with instruction for
emergency situation Adhere with the company rule
Personal Protection
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Personal Protection
Head Protection Foot Protection Eye and Face Protection Hearing Protection Hand Protection Work Clothing Safety Harness
Cleanliness And Good Housekeeping
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Cleanliness And Good Housekeeping
Ensure work place are kept clean and tidy All chemical must be stored in designated
container or area Unused equipment must be stored neatly All employees must take serious consideration
of personal hygiene to prevent spread ofdisease
Fire And Safety Design
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Fire And Safety Design
Shutdown System In the case of fire or other emergencies it is
essential to prevent the release of process
fluid or well fluid on the facilitiesFire and Gas Detection System Purposely for monitoring the facilities
protection against fire or gas release.
Emergency Plan
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Emergency Plan
Emergency plans will be developed for allPhoenix Energy managed facilities.
Safety department will establish procedures
for emergency action. Periodic drill or exercise will be carried out to
test the effectiveness of emergency plan.
Conclusion
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Co c us o
The HSE policy of Phoenix Energyimplementation can guarantee the safety ofPhoenix Energy s employee.